Downhole Device Actuator and Method

ABSTRACT

An actuator to actuate a device received on a tubular string adjacent the device. The actuator comprises an energy storage member, such as a spring, restrained in a compressed mode between a stop collar and an outer sleeve threadedly received on a threaded portion of a non-magnetic tubular segment. An outer magnet is coupled to the outer sleeve to magnetically interact with an inner magnet coupled to an inner pipe string. The inner pipe string is run into the bore of the tubular string and the outer sleeve to position the inner magnet proximal the outer magnet to form a magnetic clutch. The inner pipe string rotates to transfer torque to the outer sleeve via a magnetic clutch, to rotate and threadedly disengage the outer sleeve from the tubular segment to release energy from the energy storage member to displace the outer sleeve to engage and actuate the device.

STATEMENT OF RELATED APPLICATIONS

This application is a continuation-in-part application depending fromand claiming benefit of priority to U.S. patent application Ser. No.12/542,494 filed on Aug. 17, 2009, which is a non-provisionalapplication depending from and claiming benefit of priority to U.S.Provisional Application No. 61/089,461 filed on Aug. 15, 2008.

FIELD OF THE INVENTION

This application relates to methods and devices for downhole operationsin earthen boreholes. More specifically, this application relates toactuating a device coupled to a tubular string and run into an earthenborehole.

BACKGROUND

It is conventional practice to drill a borehole into the earth using atubular string, typically called a drill string, extending from a rig atthe earth's surface, and to cement a tubular string, typically called acasing string, in the borehole to prevent collapse and stabilize theborehole. Some boreholes may be extended in a step-wise manner, andadditional strings of casing are cemented in the borehole as part ofeach step. In some completed boreholes, a tubular string may beinstalled within the bore of the cemented casing string to facilitate,for example, the recovery of oil and/or gas from penetrated geologicformations.

Various devices may be coupled to a tubular string and actuated downholeto facilitate their installation. These devices are typically actuatedafter being run into and positioned within a borehole, e.g., in adesired location therein.

For example, but not by way of limitation, bow spring centralizers maybe used to position a casing string within a borehole for a subsequentcementing step. Bow spring centralizers may be disposed on a casingstring at spaced intervals to provide an annulus between the casingstring and the borehole. Cement slurry may be displaced through the boreof the casing string and into the annulus to form a protective cementliner therein. In boreholes having a horizontal or highly deviatedportion, more robust bow springs may be needed to provide sufficientstand-off, but more robust bow springs will increase frictionalresistance to movement of the casing string through the borehole.

One solution is to run centralizers, e.g., bow spring centralizers, onthe casing string in a retracted (e.g., collapsed) mode to reduce thefrictional resistance to movement of the casing string through theborehole. The retracted centralizers may then be deployed at a targetedinterval, e.g., to provide the desired stand-off between the casingstring and the borehole. Because the centralizers are installed on theexterior of the casing string, a challenge is presented in actuating thestand-off portion (e.g., bow spring) of the centralizers from theretracted or collapsed mode to a deployed mode without compromising theintegrity of the casing string. The centralizers are substantiallyinaccessible because they are disposed within a narrow annulus betweenthe casing string and the borehole. One attempted solution provides amethod of restraining a centralizer installed on a casing string in acollapsed mode using one or more dissolvable restraining bands, and thendissolving the bands downhole using a strong acid, such as fluoric acid,circulated into the annulus. This solution is disfavored because theacid is dangerous to handle at the surface and can damage criticalcomponents in the borehole.

Another example of a device to be actuated after it is positioned in aborehole is a packer. A packer may be used to seal off an annulusbetween two tubular strings such as, for example, an annulus between aninstalled casing string and a production string disposed within the boreof the casing string. The pressure in the annulus may be monitored sothat a leak in the casing string and/or production string can be readilydetected, e.g., for diagnoses and/or repair. A packer may be coupled toa tubular string and run into a borehole in a retracted mode and thenexpanded, e.g., to an isolating mode downhole. As above, a challenge ispresented in actuating the packer from the retracted mode to theisolating mode without compromising the integrity of the pipe string.

What is needed is an actuator that can be disposed onto a tubularstring, adjacent to a device, run into a borehole and then reliablyactivated to actuate the device without compromising the integrity ofthe tubular string to which it is coupled.

SUMMARY

Embodiments of the invention disclosed herein satisfy the above-statedneeds. For purposes of the disclosure that follows, the terms “tubular”,“tubular string” and “tubular segment” include, but are not limited to,a casing segment and/or a casing string.

One embodiment of an actuation system comprises an outer sleevethreadedly received on a threaded portion of a tubular segment betweenan energy storage member, such as, but not limited to, a spring, e.g., acompression spring, which may be in a charged (or compressed) mode tostore energy therein, and an actuatable device. A transfer device may berun into the bore of the tubular segment and rotated to activate, or“trigger,” the actuator. Upon activation, the outer sleeve of theactuator engages and manipulates the adjacent device using the energyprovided from the energy storage member, e.g., an expanding compressionspring.

In one embodiment of the system, a transfer device may be used to enablea magnetic clutch to activate the actuator. For example, an actuator maybe received on a tubular segment adjacent to an actuatable device. Theactuator may comprise an energy storage member, such as, a compressionspring, having a bore received onto the tubular segment and restrainedin a charged (or compressed) mode by an outer sleeve threadedly receivedon an adjacent threaded and non-magnetic portion of the tubular segment.A magnet is coupled to the outer sleeve, and a second magnet is coupledto an inner pipe string and run into the bore of the tubular segment andinto the bore of the outer sleeve to form a magnetic clutch. Rotation ofthe inner pipe string transfers torque to the outer sleeve through themagnetic clutch. The outer sleeve may be rotated from threadedengagement with the tubular segment to release the energy storage member(e.g., the compression spring) to a discharged (e.g., an expanded) mode.The energy storage member displaces the outer sleeve to engage andactuate the adjacent device. Energy storage members that can be used inthis application may include, without limitation, a spring (e.g.,compression spring or a coil spring) and/or a fluidic cylinder or otherchamber and/or other members to convert potential energy to kineticenergy, e.g., including the use of gravitational force.

In one embodiment, the inner pipe string may serve dual purposes,activating the actuator and pumping fluid to the borehole, such as, anacid to stimulate a formation face, a pressurized fluid to a portion ofthe borehole to test the seal of a packer or cement slurry. Moreinformation relating to an inner pipe string of the kind that canfacilitate certain embodiments of the system, method and actuatordisclosed herein is available from Davis-Lynch, Inc. of Pearland, Tex.,USA.

In one embodiment, an actuator and/or the actuatable device may beprotected from unwanted engagement with the borehole by a centralizer(or centralizers) coupled to the tubular segment adjacent to theactuator and/or the device. For example, in one embodiment, an actuatorand an adjacent actuatable device are protected from unwanted contactwith the borehole by straddling both with a pair of centralizers toprovide stand-off between the tubular string and the borehole. It shouldbe understood that the actuator may be more exposed to engagement withthe borehole in curved or irregular sections of the borehole.

An embodiment of a method of using an actuator to actuate a downholedevice disposed on a tubular string and run into a borehole includes thesteps of: receiving a device on a non-magnetic tubular segment having anadjacent externally threaded portion; threadedly receiving an outersleeve comprising a magnet on the threaded portion of the tubularsegment; receiving a compression spring restrained in a compressed modeon the tubular segment by engagement with the outer sleeve; making-upthe tubular segment into a tubular string; running the tubular stringinto a borehole to form an annulus between the outer sleeve and theborehole; rotating the outer sleeve from threaded engagement with thetubular string using a magnetic clutch; releasing the compression springfrom the compressed position to expand and displace the outer sleeve toactuate the adjacent device.

Another embodiment of the method to actuate a device on a tubular stringrun into a borehole comprises the steps of: receiving an actuatabledevice on a tubular segment; threadedly receiving an outer sleeve havinga magnet on an adjacent threaded portion of a non-magnetic portion ofthe tubular segment; receiving a compression spring in a compressed modeonto the tubular segment adjacent the outer sleeve; making-up thetubular segment into a tubular string with a tag-in receptacle alignedwith the bore of the tubular string; running the tubular string into aborehole; coupling a portion of a torque transfer device having a secondmagnet to an inner pipe string; running the inner pipe string into thebores of the tubular segment and the outer sleeve; sealably engaging theinner pipe string with the tag-in receptacle to position the torquetransfer device within the outer sleeve to form a magnetic clutch;rotating the inner pipe string to rotate the outer sleeve from threadedengagement with the tubular string; releasing the compression springfrom the compressed mode to expand and actuate the adjacent device. Inone embodiment, a magnetic clutch is formed by positioning the secondmagnet on the inner pipe string proximal the magnet on the outer sleeveto form a magnetic clutch. The interaction of the magnets enablestransfer of torque from the inner pipe string to the outer sleeve torotate the outer sleeve and thereby threadedly disengage the outersleeve from the externally threaded portion of the tubular string. Aplurality of second magnets may be coupled to the inner pipe string in afirst pattern to interact with a plurality of magnets coupled to theouter sleeve in a coincident pattern.

It should be noted that an outer sleeve having a magnet and an innerpipe string having a second magnet may be used to form a magnetic clutchand to actuate, operate or otherwise magnetically engage mechanismsother than the threadedly engaged outer sleeve described herein. Forexample, but not by way of limitation, the inner string may bemanipulated along an axis (e.g., longitudinally manipulated) of thetubular string to move a tab (e.g., within the inner sleeve) into orfrom a slot (e.g., on the exterior of the tubular string) to couple ordecouple one component to or from the other. The tab and the slot may bejuxtaposed so that the tab is on the tubular string and the slot iswithin the outer sleeve. Such axial manipulation may be usedindependently of or in conjunction with other uses of the magneticclutch disclosed herein.

BRIEF DESCRIPTION OF THE DRAWINGS

The foregoing and other features and aspects will be best understoodwith reference to the following detailed description of embodiments ofthe invention, when read in conjunction with the accompanying drawings,wherein:

FIG. 1 is an elevation view of an embodiment of the actuator in a run-inmode and disposed on a tubular segment adjacent to a centralizer havingflexible ribs.

FIG. 2 is an elevation view of the actuator of FIG. 1 in an activatedmode to actuate the centralizer.

FIG. 3 is an elevation view of the apparatus of FIG. 1 with an innerpipe string and torque transfer device superimposed thereon toillustrate a magnetic clutch.

FIG. 3A is an elevation view of an embodiment of a transfer device on aninner pipe string and a plurality of magnets coupled to the torquetransfer device to interact with the plurality of magnets coupled to theouter sleeve of FIG. 3.

FIG. 4A is an elevation section view of an actuatable packer having apacking member received between a first collar and a second collaradjacent the outer sleeve of the actuator.

FIG. 4B is the packer of FIG. 4A after the outer sleeve of the actuatordisplaces the second collar towards the first collar to radially expandthe packing member.

FIG. 5A is an elevation section view of a valve having a closure sleevemovably received between the outer sleeve of the actuator and a back-upspring and in a closed position to cover fluid ports in the tubularstring.

FIG. 5B is the view of FIG. 5A after the outer sleeve of the actuatordisplaces the closure sleeve from the closed position to an openposition to permit fluid flow through the fluid ports.

DETAILED DESCRIPTION

The following detailed description refers to the above-listed drawingswherein depicted elements are not necessarily shown to scale and whereinlike or similar elements are designated by the same reference numeralthrough the several views.

FIG. 1 is an elevation view of an embodiment of an actuator 5 in arun-in mode and disposed on a non-magnetic tubular segment 8 adjacent toan actuatable centralizer 9 having flexible ribs 16, e.g., ribs in acollapsed position. The illustrated actuator 5 comprises a compressionspring 7 and an adjacent outer sleeve 10 comprising a plurality ofmagnets 48B and an internally threaded portion 10A (shown in FIG. 1 indotted lines) threadedly received on an externally threaded portion 8A(also shown in dotted lines) of the tubular segment 8. Energy storagemember is depicted as a compression spring 7 which is also illustratedin a charged or compressed (run-in) mode to store energy therein, andthe compression spring 7 is restrained in the compressed mode between acollar 22, e.g., a stop collar as known to one of ordinary skill in theart, and the outer sleeve 10. A thrust bearing 30 may be disposedintermediate the compressed spring 7 and the outer sleeve 10 to limitfriction resistance to rotation of the outer sleeve 10 relative to thecompressed spring 7.

The actuator 5 is shown received on a tubular segment 8 adjacent to acentralizer 9 for purposes of illustration only. It should be understoodthat the actuator 5 may be used in conjunction with a variety ofactuatable devices. The centralizer 9 disposed adjacent to the outersleeve 10 in FIG. 1 comprises a plurality of ribs 16 coupled between afirst collar 12 and a second, e.g., moving, collar 14 that is adjacentto, but spaced from, the outer sleeve 10 of the actuator 5. The ribs 16of the centralizer 9 are shown in FIG. 1 in a substantially flattenedconfiguration. Optionally, a gap 11 may separate the second collar 14 ofthe centralizer 9 from engagement with the outer sleeve 10 of theactuator 5. While FIG. 1 illustrates the first collar 12 of thecentralizer 9 disposed adjacent to a stop collar 20, it should beunderstood that the stop collar 20 may be integrally formed with orcoupled to the first collar 12 to, for example, maintain a gap 11between the outer sleeve 10 of the actuator 5 and the centralizer 9.Optionally, a stop collar 13 may be positioned between the first collar12 and the second collar 14 to limit expansion of the centralizer 9 asdescribed below in connection with FIG. 2.

FIG. 2 is an elevation view of the actuator 5′ of FIG. 1 in an activatedor released mode to actuate the adjacent centralizer 9′ to a deployedmode. The outer sleeve 10′ is shown axially displaced after beingrotated from threaded engagement with the non-magnetic tubular segment8. Upon threaded disengagement, the outer sleeve 10 of FIG. 1 isreleased to move along the tubular segment 8 in response to forceapplied by the compression spring 7 to the position shown in FIG. 2. Theouter sleeve 10′ is shown in FIG. 2 after engaging the second collar 14′at sleeve end 10B and displacing the second collar 14 toward the firstcollar 12 to a position corresponding to a deployed mode of thecentralizer 9′. The first collar 12 of the centralizer 9′ is restrainedagainst movement by stop collar 20. The ribs 16′ are shown in FIG. 2 ina deployed mode, e.g., extended, to provide stand-off between thetubular segment 8 and the wall 4A of the borehole 4. The displacement ofthe outer sleeve 10′ from its position in FIG. 1 corresponds to theseparation between the interior threads 10A of the outer sleeve 10′ fromthe externally threaded portion 8A of the non-magnetic tubular portion 8illustrated in FIG. 2.

FIG. 3 is an elevation view of the actuator of FIG. 1 with the positionof an inner pipe string superimposed thereon to illustrate a magneticclutch. The magnetic clutch illustrated in FIGS. 3 and 3A comprises aplurality of magnets 48B coupled to the outer sleeve 10 (see FIG. 3) anda transfer device 34 comprising a plurality of magnets 48A coupled tothe inner pipe string 36 (e.g., a magnet retainer 46 in FIG. 3A). Thetransfer device 34 illustrated in FIG. 3A (and shown in dotted lines inan engaged position within the outer sleeve 10 in FIG. 3) magneticallycouples the outer sleeve 10 to the inner pipe string 36 to provide amagnetic clutch. Rotation of the inner pipe string 36 transfers torqueto the outer sleeve 10 through the magnetic clutch, and the magneticinteraction is enabled by a non-magnetic tubular segment 8 through whichthe magnetic interaction occurs. The threaded interface between theexternally threaded portion 8A of the tubular segment 8 and theinternally threaded portion 10A of the outer sleeve 10 is exaggerated inthe illustration of FIGS. 1-3. These threads may be fine threads havinga small pitch and a large thread count (threads per inch or cm) tominimize the torque required to threadedly disengage the outer sleeve 10from the tubular segment 8.

The magnets 48B of the outer sleeve 10 in the embodiment illustrated inFIG. 3 are arranged in a generally columnar pattern. A variety ofarrangements of the magnets 48B may be used, and the arrangementillustrated in FIG. 3 is but an example of how the magnet(s) 48B mightbe arranged on the outer sleeve 10. For example, three separate columnararrangements of magnets may be angularly distributed, e.g., at 120degree intervals. The magnets 48A on the inner pipe string 36 may becoupled to the magnet carrier 46 of FIG. 3A in an arrangement generallycoinciding with the arrangement of the magnets 48B on the outer sleeve10 of FIG. 3. In some embodiments, the inner pipe string 36 may comprisea bore (not shown in FIG. 3A) through which a fluid, for example, acement slurry, an acid or a pressurized fluid, may be provided to an end(not shown in FIG. 3A) of a tubular string into which the tubularsegment 8 is included.

The transfer device 34 of FIG. 3A may include a first spacer 43A and/ora second spacer 43B straddling the magnet carrier 46 to radiallyposition the magnets 48A within the bore of the non-magnetic tubularsegment 8 (see FIG. 3) when the inner pipe string 36 is run into thetubular segment 8. The first and/or second spacers 43A, 43B are shown inFIG. 3A as generally triangular in shape, but may comprise a variety ofshapes without loss of function.

The actuator 5 described above in connection with FIGS. 1 through 3A maybe used to actuate a variety of devices used in downhole operations. Theenergy stored in the compression spring 7 of the actuator 5 and releasedupon activation to displace the outer sleeve 10 as disclosed above maybe used to actuate, for example, a centralizer 9, as shown in FIGS. 1and 2, a packer 6 (as discussed in more detail in relation to FIGS. 4Aand 4B below), a cement basket, a casing hanger, an openable fluid port(as discussed in more detail in relation to FIGS. 5A and 5B below), andmany other actuatable devices.

The device to be actuated may be positioned to minimize or preventfrictional resistance to rotation of the outer sleeve. For example,FIGS. 1 and 3 illustrate a gap 11 that may be disposed between themoving collar 14 of the centralizer 9 and the outer sleeve 10 of theactuator 5. In one embodiment of the method of using the actuator 5, thecentralizer 9 may be restrained from sliding on the non-magnetic tubularsegment 8 to maintain a gap 11 and prevent the device which is, in theillustrations in FIGS. 1 and 3, a centralizer 9, from frictionallyengaging the outer sleeve 10 as it rotates toward threaded disengagementfrom the tubular segment 8. FIGS. 1 and 3 illustrate a slightly bowedconfiguration of the ribs 16 of the centralizer 9 in the collapsed orretracted mode to ensure that the ribs 16, upon actuation by theactuator (see element 5 in FIGS. 1 and 3), deploy to the bowed modeillustrated in FIG. 2. It should be understood that straight ribs couldload upon engagement by the outer sleeve 10 in a compressive mode, likea column, and thereby prevent full expansion of the compression spring 7(see FIG. 2).

FIG. 4A is a sectional elevation view of a packer 6 having a generallysleeve-shaped packing member 60 received onto the tubular segment 8between a first collar 40 and a moving collar 42 adjacent the outersleeve 10. The packing member 60 may be, for example, but withoutlimitation, an elastic polymer, rubber, or some other resilient, solidmaterial. The tubular segment 8 of FIG. 4A is illustrated as threadedlyincluded within a tubular string disposed within a larger tubular string2 having an interior bore 2A. The packing member 60 of the packer 6 isillustrated in FIG. 4A in its retracted mode to allow fluidcommunication between an uphole portion 12A of the borehole 12 above thepacker 6 to a downhole portion 12B below the packer 6. A gap 11 may bedisposed between the moving collar 42 of the packer 6 and the outersleeve 10 of the actuator 5 to prevent the moving collar 42 fromfrictional engagement with the outer sleeve 10 when the outer sleeve 10is rotated to threadedly disengage the interior threads 10A from thethreaded portion 8A of the non-magnetic tubular segment 8 to release thecompression spring 7 to move the outer sleeve 10.

FIG. 4B is the packer of FIG. 4A after the outer sleeve 10′ threadedlydisengages the tubular segment 8 and displaces the second collar 42′against the packing member 60′ to close the gap 11′ and axially compressthe packing member 60′ between the first collar 40 and the second, e.g.,moving collar 42′ to actuate the packer 6′ to an expanded mode. Thepacking member 60′ may thus be radially expanded to seal against theinterior bore 2A of the larger tubular string 2 to isolate the upholeannular portion 12A from the downhole annular portion 12B. The magnetretainer 46 generally remains in its position relative to the largertubular string and the non-magnetic tubular portion 8 as the outersleeve 10′ moves along the tubular segment 8 under the force of thecompression spring 7′ a distance corresponding to the separation betweenthe interior threads 10A of the outer sleeve 10′ from the threadedportion 8A of the non-magnetic tubular segment 8.

FIG. 5A is an elevation view of a valve 15 having a closure sleeve 21movably received between the outer sleeve 10 and a back-up spring 27 andin a closed position to cover fluid ports 8B in the tubular segment 8.In the embodiment shown in FIGS. 5A and 5B, a pusher sleeve 19 havingflow passages 19A is disposed intermediate the closure sleeve 21 and theouter sleeve 10. Optionally, a gap 11 may be disposed between the pushersleeve 19 and the outer sleeve 10.

FIG. 5B is the elevation view of FIG. 5A after the outer sleeve 10′ isreleased to displace the closure sleeve 21′ along the tubular segment 8from the closed position to an open position to permit fluid flowthrough the fluid ports 8B. The back-up spring 27′ is shown in acompressed mode as acted upon by the larger compression spring 7′through the outer sleeve 10′, pusher sleeve 19′, and closure sleeve 21′.The flow passages 19A of the pusher sleeve 19′ are aligned with thefluid ports 8B in the tubular segment 8 to establish fluid communicationbetween the bore 8C of the tubular segment 8 and the annulus 2B betweenthe tubular segment 8 and the wall 2A of the larger tubular 2.

It should be understood that embodiments of the system, actuator and themethod of using the actuator may be used in an open borehole, asillustrated in FIGS. 1 and 2, or in a cased hole, as illustrated inFIGS. 4A through 5B, to simultaneously or separately actuate a pluralityof actuatable devices of the same or different kinds that may be coupledto a tubular string and run into a borehole. For example, bymanipulating the thread pitch or thread count of one actuator ascompared to another, the number of rotations of the inner pipe string,after the magnetic clutch is formed by positioning of the inner pipestring, can be used to vary the sequence or timing of actuation of aplurality of devices coupled to the tubular string. For example, aninner pipe string could be rotated to actuate a first actuatable device,then operations could commence, followed by further rotation to actuatea second actuatable device.

The magnets used in embodiments of the invention may or may not compriserare earth magnets or electromagnets. A non-magnetic tubular segment 8is provided to enable the magnetic interaction between the magnets 48Aon the inner pipe string 36 and the magnets 48B on the outer sleeve 10,and the non-magnetic tubular segment 8 may be, for example, stainlesssteel. It should be understood that embodiments of the invention usingmultiple outer sleeves driven, using magnetic couplings between theinner pipe string and the outer sleeves, may continue to effectivelyfunction notwithstanding disablement of one or more outer sleeves dueto, for example, contact with the borehole. For example, should an outersleeve engage the borehole, for example, at a borehole irregularity ordeviation, the inner string is not disabled from continued rotationwithin the bore of the tubular string, and other outer sleeves maycontinue to rotate to threaded disengagement in response to rotation ofthe inner pipe string without damage to or substantial impairment of theintended benefit provided by the invention.

The terms “comprising,” “including,” and “having,” as used in the claimsand specification herein, shall be considered as indicating an opengroup that may include other elements not specified. The terms “a,”“an,” and the singular forms of words shall be taken to include theplural form of the same words, such that the terms mean that one or moreof something is provided. The term “one” or “single” may be used toindicate that one and only one of something is intended. Similarly,other specific integer values, such as “two,” may be used when aspecific number of things is intended. The terms “preferably,”“preferred,” “prefer,” “optionally,” “may,” and similar terms are usedto indicate that an item, condition or step being referred to is anoptional (not required) feature of the invention. “Non-magnetic,” asthat term is used herein, refers to a substance that is substantiallyunaffected by, or does not substantially interfere with, a magneticfield. Non-limiting examples of non-magnetic substances includepolymers, stainless steel, copper (e.g., nickel-copper alloy), aluminumand combinations thereof. However, the use of the term “non-magnetic”does not necessarily require the absolute absence of any substance thatmay be affected by or interfere with a magnetic field. For example, itis within the scope of the invention for a non-magnetic tubular segmentto have articles disposed thereon or included therein that aresufficiently small so as not to substantially affect or interfere with amagnetic field.

From the foregoing detailed description of specific embodiments of theinvention, it should be apparent that a system for enhancing the qualityof cementing operations that is novel has been disclosed. Althoughspecific embodiments of the system are disclosed herein, this is donesolely for the purpose of describing various features and aspects of theinvention, and is not intended to be limiting with respect to the scopeof the invention. It is contemplated that various substitutions,alterations, and/or modifications, including but not limited to thoseimplementation variations which may have been suggested herein, may bemade to the disclosed embodiments without departing from the spirit andscope of the invention as defined by the appended claims which follow.

While the invention has been described with respect to a limited numberof embodiments, those skilled in the art, having benefit of thisdisclosure, will appreciate that other embodiments can be devised whichdo not depart from the scope of the invention as disclosed herein.Accordingly, the scope of the invention should be limited only by theattached claims.

1. A method of actuating a device comprising the steps of: threadablyreceiving an outer sleeve, comprising a magnet, on an externallythreaded portion of a non-magnetic tubular segment made up into atubular string, the outer sleeve positioned intermediate the device andan adjacent energy storage member in a charged mode; running the tubularstring into an earthen borehole; running a second magnet disposed on aninner pipe string into a bore of the non-magnetic tubular segment toposition the second magnet proximal the magnet of the outer sleeve toform a magnetic clutch; rotating the inner pipe string to rotate theouter sleeve from threaded engagement with the non-magnetic tubularsegment using the magnetic clutch; releasing energy stored in the energystorage member to displace the outer sleeve to actuate the device. 2.The method of claim 1 further comprising the steps of: disposing acentralizer having a first collar, a second collar and a plurality offlexible ribs therebetween adjacent the outer sleeve; securing at leastone of the first and second collars of the bow spring centralizer to thetubular string; and displacing the other of the first and second collarsof the bow spring centralizer toward the one of the first and secondcollars to radially deploy the bow springs.
 3. The method of claim 1further comprising the steps of: disposing a packing member intermediatea first collar and a second collar adjacent the outer sleeve; securingthe first collar to the tubular string; and displacing the second collartoward the first collar to radially deploy the packing member.
 4. Themethod of claim 1 further comprising the steps of: disposing a cementbasket having a first collar and a second collar adjacent the outersleeve; securing at least one of the first and second collars of thecement basket to the tubular string; and displacing the other of thefirst and second collars of the cement basket toward one of the one ofthe first and second collars to radially expand the cement basket. 5.The method of claim 1 further comprising the steps of: displacing asleeve relative to a fluid port; wherein the device is a valve.
 6. Themethod of claim 1 wherein the energy storage member comprises a spring.7. An actuator to actuate a device disposed on a tubular string run intoa borehole, comprising: an energy storage member intermediate a firstcollar and an outer sleeve threadedly received on a threaded portion ofa non-magnetic tubular segment adjacent the device, the outer sleevecomprising a magnet; and an inner pipe string to position a secondmagnet within the bores of the non-magnetic tubular segment and theouter sleeve to magnetically couple the inner pipe string to the outersleeve; wherein rotation of the inner pipe string in a first directionrotates the outer sleeve from threaded engagement with the non-magnetictubular segment to release the energy storage member from a charged modeto displace at least one component of an actuatable device.
 8. Theapparatus of claim 7 further comprising a thrust bearing rotatablydisposed intermediate the energy storage member and the outer sleeve. 9.The apparatus of claim 7 further comprising: a second stop collarcoupled to the non-magnetic tubular segment in a spaced-apartrelationship from the first stop collar to together straddle the energystorage member, the outer sleeve and the device.
 10. The apparatus ofclaim 7 wherein the non-magnetic tubular segment comprises stainlesssteel.
 11. The apparatus of claim 7 wherein the non-magnetic tubularsegment is removably attachable to a tubular string.
 12. The apparatusof claim 7 wherein the energy storage member comprises a spring.
 13. Adeployable centralizer comprising: an energy storage member intermediatea first stop collar and an outer sleeve threadedly coupled to anon-magnetic tubular segment adjacent the downhole device, the outersleeve comprising a magnet; an inner pipe string to position a secondmagnet within the bores of the non-magnetic tubular segment and theouter sleeve to magnetically couple the inner pipe string to the outersleeve; a centralizer having a plurality of flexible ribs coupledbetween a first end collar and a second end collar, the centralizerintermediate a second stop collar and the outer sleeve; wherein threadeddisengagement of the outer sleeve from the tubular segment releasesenergy from the energy storage member to displace the second end collartoward the first end collar to bow the ribs.
 14. The deployablecentralizer of claim 13 wherein the second stop collar is integral withthe first end collar of the centralizer.
 15. The deployable centralizerof claim 13 comprising a stop collar disposed intermediate the first endcollar and the second end collar.
 16. The deployable centralizer ofclaim 13 further comprising a thrust bearing disposed between the outersleeve and the energy storage member.
 17. The deployable centralizer ofclaim 13 wherein the non-magnetic tubular segment comprises stainlesssteel.
 18. A deployable packer to engage a bore comprising: an energystorage member intermediate a first stop collar and an outer sleevethreadedly coupled to a non-magnetic tubular segment, the outer sleevecomprising a magnet; and an inner pipe string to position a secondmagnet within the bores of the non-magnetic tubular segment and theouter sleeve to magnetically couple the inner pipe string to the outersleeve; a second stop collar coupled to the tubular segment in aspaced-apart relationship with the first stop collar to togetherstraddle the energy storage member and outer sleeve; and a packingmember received on the tubular segment intermediate the second stopcollar and the outer sleeve; wherein upon rotation of the inner pipestring, the outer sleeve threadedly disengages the outer sleeve from thenon-magnetic tubular segment to allow the energy storage member todisplace the outer sleeve against the packing member; wherein thepacking member is radially expanded by engagement with the outer sleeveto engage a bore.
 19. The deployable packer of claim 18 wherein thenon-magnetic tubular segment comprises stainless steel.
 20. Thedeployable packer of claim 18 further comprising a thrust bearingdisposed between the outer sleeve and the energy storage member.
 21. Thedeployable packer of claim 18 wherein the energy storage membercomprises a spring.
 22. A method of deploying a centralizer to anexpanded mode within a bore comprising the steps of: threadablyreceiving an outer sleeve having a magnet on an externally threadedportion of a non-magnetic tubular segment made up into a tubular string,the outer sleeve positioned intermediate a centralizer and an energystorage member; running the tubular string into an earthen borehole;running a second magnet on an inner pipe string into a bore of thenon-magnetic tubular segment to position the second magnet proximal themagnet of the outer sleeve to form a magnetic clutch; rotating the innerpipe string to rotate the outer sleeve from threaded engagement with thenon-magnetic tubular segment; and releasing energy from the energystorage member to displace the outer sleeve against an end collar of thecentralizer to deploy the centralizer to an expanded mode.